27 & 29 May 2014 The information in this presentation: Is not - - PowerPoint PPT Presentation

27 & 29 May 2014

The information in this presentation:

• Is not an offer or recommendation to purchase or subscribe for shares in Cooper Energy Limited or to retain or sell any shares that are

currently held.

• Does not take into account the individual investment objectives or the financial situation of investors.
• Was prepared with due care and attention and is current at the date of the presentation.

Actual results may materially vary from any forecasts (where applicable) in this presentation. Before making or varying any investment in shares of Cooper Energy Limited, all investors should consider the appropriateness of that investment in light of their individual investment objectives and financial situation and should seek their own independent professional advice.

Qualified petroleum reserves and resources evaluator

This report contains information on petroleum resources which is based on and fairly represents information and supporting documentation reviewed by Mr Andrew Thomas who is a full time employee of Cooper Energy Limited holding the position of Exploration Manager, holds a Bachelor of Science (Hons), is a member of the American Association of Petroleum Geologists and the Society of Petroleum Engineers and is qualified in accordance with ASX listing rule 5.41 and has consented to the inclusion of this information in the form and context in which it appears.

Rounding

All numbers in this presentation have been rounded. As a result, some total figures may differ insignificantly from totals obtained from arithmetic addition of the rounded numbers presented.

Key figures Share price range, 12 months $0.35 - $0.585 Shares on issue 329.2 mill Market capitalisation1 $172.8 mill Cash & investments2 $79.7 mill Debt Nil Production MMbbl /year 0.57 – 0.60 Share register Top 20 holders~66% Funds/Corp ~67% Well resourced with strong balance sheet

0.30 0.35 0.40 0.45 0.50 0.55 0.60 May- 13 Jun- 13 Jul-13 Aug- 13 Sep- 13 Oct- 13 Nov- 13 Dec- 13 Jan- 14 Feb- 14 Mar- 14 Apr- 14 May- 14 (1) As at 23 May 2014 (2) As 31 March 2014

• Management team experienced in Australia and Indonesia
• Proven capabilities in developing and commercialising gas
• Record of success in large and small Australian and international companies
• Clear strategy addresses opportunities in Australian energy market
• Selective approach based on commercial and technical fundamentals
• Cash and financial assets of $79.7 million2
• Supported by financial facilities of $40 million
• 500,000+ barrels pa oil with netback of A$97/bbl1 after costs from Cooper Basin
• 5th largest onshore oil producer in Australia
• Growing Indonesian oil production
• Australia: high margin/ high success oil exploration, conventional & unconventional gas exploration
• Gippsland: gas/liquids development project
• Indonesia: material upside at low cost

1 COE Cooper Basin 2014 first half netback after costs 2 As at 31 March 2014

Production, cash, earnings, & management High margin, strong cash- generating oil production Strong balance sheet and financial resources Prospective acreage and development opportunities Experienced and proven management and board Disciplined strategy focused

• n TSR

Oil & Gas Australia and Indonesia

Total Shareholder Return

and

Health Safety Environment Community People

• Extensive knowledge
• Delivery record
• Remuneration & results linked

Funding

• Strong balance sheet
• Robust cash flow
• Finance facilities

Assets

• Cooper Basin
• Otway Basin
• Gippsland Basin
• South Sumatra, Indonesia

Strategy

• Fundamentals focus: market, technical, cost & commercial
• Leverage and grow strengths
• High margin oil
• Gas portfolio

Leveraging strengths for TSR

$ million unless otherwise indicated

H1 14 H1 13 Production MMbbl 0.30 0.21 ▲ + 41% Sales volume MMbbl 0.29 0.21 ▲ + 37% Sales revenue 37.0 23.4 ▲ + 58% Net profit after tax 13.6 4.6 ▲ + 198 % Cash flow from operations 24.2 2.1

▲

+1,034%

• Record half-year profit driven by increased production, prices and reduced costs
• New resources upside identified and acquired:

−

Cooper Basin (Worrior oil field Patchawarra Formation)

−

Gippsland Basin (Basker Manta Gummy [BMG] gas and liquids)

−

Tunisia (Hammamet West oil field)

On track for record earnings

• Record of increasing reserves and production
• Expect trend to continue in FY14

324 415 14 41

FY13 FY14

Indonesia Cooper Basin Year to date production kbbl nine months to March

• Production growth from both Cooper Basin and Indonesia
• Cooper Basin: new wells connected and drilling
• Indonesia: well workover program and drilling

Sustained and ongoing growth

0.0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9

0.0 1.0 2.0 3.0

2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 2014 est Production MMbbl

2P Reserves (MMbbl) 2P Reserves Production *

* 2014 Reserves to be calculated as at 30 June 2014

Cooper Basin Oil

• Oil production
• Development & appraisal
• Exploration

Otway Gas

• Exploration

Gippsland Gas & Oil

• Development
• Appraisal & exploration

Indonesia (onshore Sumatra)

• Oil production, development and appraisal
• Oil & gas exploration

Tunisia (being divested)

Production: ~0.6 MMbbl pa High margin & cash generation Cooper Basin, Western Flank Indonesia, South Sumatra Sustained exploration success Market, cost & value focused BMG Project, Gippsland Otway Basin Cooper Basin Proven capability in gas commercialisation Basin focussed strategy Production growth Low risk value-add Material exploration upside CBM and shale potential Introduce partners Cash & financial assets $80 mill Finance facilities $40 mill Strategy driven acquisitions Technical capability and experience Tunisia monetisation

• Oil production and exploration
• current approximately 1,500 bopd (net)
• Exploration and development continues to add reserves
• Cooper Energy Cooper Basin cumulative exploration

success rate of 33% from FY03 – FY13

• new opportunities such as Patchawarra oil in PEL 93
• Extensive seismic acquisition completed for drilling in

2014-15

• 3 exploration wells planned for June quarter 2014

Valuable production + high success rates

7 15

9 97 Netback Royalties Transportation Production

100 200 300 400 500 600 700 800 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030

PJ Surat-Bowen Bass Otway Gippsland Cooper

New supply contract opportunity Forecast east cost domestic demand

Contracted supply from:

Source: EnergyQuest

• Supply opportunity incorporated into COE

strategy from 2012

• Built market understanding; buyer

relationships; cost curve positions; and development timelines

• Rising gas prices
• Application of COE gas commercialisation

expertise Market opportunities

Gippsland Basin: Eastern Australia’s largest gas source:

• BMG Project: 65% interest & Operator
• Hold 22.9% interest in Bass Strait Oil Company (BAS)

Otway Basin: ideally located

• Built acreage position through acquisition and trades
• Position covers most of Casterton Formation play

Cooper Basin: existing infrastructure

• Evaluating opportunities

Energy market driven

Building a competitive supply portfolio

65% interest holder and Operator of BMG gas and liquids project

• Existing wells and gas-gathering infrastructure
• Economic enhancement options through adjacent fields & infrastructure
• To be included in year-end review of resources and reserves

Developing Business Case for optimum development

• Available by mid - 2015
• Equity levels to be leveraged for capital efficiency
• Gas buyers have registered interest
• Target: gas supply to Eastern Australia by 2018

22.9% interest holder in Bass Strait Oil Company

• Acreage adjacent to BMG

Conventional gas close to market

• Strong position across Penola Trough
• Proven basin for conventional plays
• Close to markets and infrastructure
• Jurassic source rocks are gas prone with liquids

potential

• 2 deep (approx 4,000m) wells from January 2014
• Jolly-1: reinforced Casterton Formation potential and

identified potential for deep stratigraphic trapping

– gas shows over 340m sandstone interval in Lower

Sawpit

– cores collected being analysed

• Bungaloo-1 currently drilling

– primary objective to gather further information on Casterton Formation – will also assess sands in Lower Sawpit

Proven gas province, close to market

• Prolific hydrocarbon region
• 285 discoveries
• 3 billion bbl oil & 25 TCF gas
• Not rigorously explored with 3D
• Emerging Coal Bed Methane (CBM) & shale

plays

• US$8 - 10/GJ gas prices & market access
• Existing infrastructure
• Fit with COE skill set

High potential, proven prospectivity

Sukananti KSO (COE 55%)

• Currently ~300 bopd (100% basis)
• Multiple low risk development opportunities
• 2 workovers plus development drilling planned from mid-2014
• Targeting production growth
• Contractor share: oil 15%: gas 20%1

Sumbagsel PSC (COE 100%)

• Shallow oil targets
• Identifying best targets from 2013/14 seismic for 2015 drilling
• Farm out from 100% for capital efficient drilling
• Contractor share: oil 25%: gas 40%1

Merangin III PSC (COE 100%)

• Highly prospective & large prospects
• Reprocessing seismic to inform 2015 seismic program
• Farm out from 100% for capital efficient drilling
• Contractor share: oil 30%: gas 35%1

Production and high value exploration

• 1. After tax

• 3 permits covering 12,600 km2
• Hammamet West oil discovery
• gross contingent resource estimated to be

12.6 MMboe (1C) to 110.4 MMboe (3C)1

• oil development opportunity
• to be tested further by Hammamet West-3 ST-

2 in 2015

• Multiple prospects

Divestment plan

• Data room opened March 2014
• Aiming for completion during 2014

Realise value from sale to natural owner

• 1. 100% Joint Venture resource as announced to ASX 28 April 2014 (the Announcement). Cooper Energy confirms that it is not aware of any new information or data that materially affects the information included in the

Announcement and that all the material assumptions and technical parameters underpinning the estimates in the Announcement continue to apply and have not materially changed.

FY 14 FY 15 FY 16 FY 17 FY 18 FY 19 FY 20 FY 21 FY 22 FY 23 Net Production mmboe

• Sustain and grow existing production and

cashflow

• Transformational impact from gas strategy

– especially BMG development

• Exploration in Cooper Basin, Otway Basin

and Indonesia offer further upside

• Application of cash flow for acquisitive

growth that aligns with strategy

Exploration:

• Indonesia, Otway, Cooper Basin

Acquisitions Existing Production: Cooper Basin, Indonesia Gippsland:

• BMG Commercialisation
• Exploration

Step changes in production anticipated

• FY14 Production guidance upgraded to 575,000 – 600,000 barrels of oil, up 18% - 22% on FY13
• Record financial results forecast
• FY14 Reserves and Resources to include significant additions for Gippsland and Hammamet West

Plus numerous value-adding catalysts in the near term

• Announcement of FY14 financial results: 18 August 2014
• Exploration drilling in Cooper Basin: ongoing
• Tunisia: divestment or successful test at Hammamet West ST-2 (H1 15)
• BMG business case (mid - 2015)
• Otway Basin results, analysis and further activity (FY15)
• Drilling in Indonesia: activity 2014 onwards
• Value-focussed acquisitions

Performing strongly

Appendices

• Reserves and resources updated annually as

at 30 June 2014

• Resources as at 2014 to include additions

for:

–

Tunisia: 11 MMboe 2C resource announced April 20144

–

BMG: resources attributable to field to be assessed and incorporated

Reserves1

MMbbl as at 30 June 2013

1P 2P 3P Cooper Basin 0.95 1.80 2.89 Indonesia 0.06 0.35 0.64 Total 1.02 2.16 3.53

Contingent Resources1

MMboe as at 30 June 2013

1C 2C 3C Cooper Basin 0.00 0.00 0.03 Tunisia 2 5.15 5.74 6.41 Total3 5.15 5.74 6.44

1 As per Cooper Energy 2013 Annual Report 2 Does not include Hammamet West 3 Does not include Gippsland Basin 4 Contingent Resource as announced to ASX 28 April 2014 (the

Announcement). Cooper Energy confirms that it is not aware of any new information or data that materially affects the information included in the Announcement and that all the material assumptions and technical parameters underpinning the estimates in the Announcement continue to apply and have not materially changed

.

2 4 6 8 10 12 14 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033

Annual gas prices ($/GJ, $95 oil, 2013$)

Sydney Adelaide Melbourne Gladstone Brisbane

Source: EnergyQuest

Conventional CSG Tight conventional Shale

• Liquids content
• Inerts content e.g. CO2, N2
• Size/economy of scale
• Community & approvals
• Access to infrastructure
• Distance/cost to market

• 3 wells planned before end of FY14
• Seismic interpretation of the Irus and

Caseolus 3D ongoing to add to drilling portfolio

• Seismic reprocessing and inversion

underway to address existing Namur play and emerging Birkhead Channel play

• Drilling activity levels in FY15 similar to FY14

levels

Morgan-1 Fishery-1 Shelley-1

• Worrior-8 flowed 670 barrels of oil per day with 0.7 million standard cubic feet of gas in 2013
• Worrior-10 intersected 4.5m net oil pay
• Reserve potential under evaluation
• Plan to drill further appraisal wells in FY15

Patchawarra Depth Map (5m)

9 6 5 3 2 4 7 Pando 1 Worrior 1

Worrior-10 Worrior-8

Pando-1 Worrior-3 Worrior-8 Worrior-1 Worrior-10

Pando\Worrior Paleo-High

Patchawarra Formation

250

250

250

250

Murteree Shale

5 metres

7.3MMcfd & 60 bcpd 1 Extended Production Test scheduled May 14 0.7MMcfd & 670 bopd

1 Barrels condensate per day

Eumeralla Formation Basement Casterton Shale Jolly-1 Bungaloo-1

Sawpit-1 Sawpit-2

Salamander-1 Aquifer

South North

Pretty Hill Formation

Casterton Shale

Laira Formation Dilwyn Formation Subsurface fault

4000 metres 2000 metres 500 metres

Not to Scale

Casterton Formation gas maturity window

Casterton gas maturity window

• First half production up from 54 bopd

to 158 bopd (COE share) due to successful workover initiative

• 2 workovers planned for second half

FY14

• Development/appraisal drilling

planned from mid 2014

• Targeting further production growth

Production, exploration and development

• COE awarded permit April 2011 for a 6

year initial exploration term

• Acquired 257 km of 2D seismic
• Key play types are structural and

carbonate reefs

• Typical prospect sizes 5-10 MMbbl oil
• CBM potential
• Forward plan

‒complete new seismic interpretation ‒update prospect portfolio ‒farm-out equity to reduce capital risk ‒drill prospect FY15

• COE awarded permit May 2013 for a 6 year exploration initial term
• Key play types are structural and carbonate reefs
• Shallow oil prospect potential 5-10MMbbl
• Deep gas prospect potential 100 to > 500Bcf
• CBM potential
• Forward plan

‒complete new seismic interpretation

and prospect portfolio update

‒farm-out equity to reduce capital risk ‒acquire new seismic in FY15

Gross Contingent Resource Estimates 1C (P90) 2C (P50) 3C (P10) Oil MMbbl 11.6 34.5 99.8 Gas2 Bcf 5.3 17.9 59.7 Total Mmboe3 12.6 37.7 110.4 Net 4 Contingent Resource Estimates for Cooper Energy Oil MMbbl 3.5 10.4 29.9 Gas2 Bcf 1.6 5.4 17.9 Total MMboe 3.8 11.3 33.1

1Gross: Contingent Resources attributable to 100% joint venture interest in Bargou

Permit, Tunisia

2 Gas: Associated gas dissolved in oil at reservoir conditions 3 MMboe: Million barrels of oil equivalent. Conversion factor of 1 boe = 5,620 scf

(1 Bcf = 0.178 MMboe)

4 Net: Contingent Resources attributable to Cooper Energy’s 30% interest in

Bargou Permit, Tunisia

*. Contingent Resource as announced to ASX 28 April 2014 (the Announcement). Cooper Energy confirms that it is not aware of any new information or data that materially affects the information included in the Announcement and that all the material assumptions and technical parameters underpinning the estimates in the Announcement continue to apply and have not materially changed.